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Collaborating Authors
Waterflooding
Optimizing Waterflooding Schemes and Completion Decisions in Deepwater environments using Formation Pressure While Drilling (FPWD): A Bonga Field Application
Adoghe, Leo (Petrophysicist-Shel) | Effiom, Oghogho (Geologist-Shell) | Bakare, Olatunji (Reservoir Engineer-Shell) | Nkanga, Akanimoh (Schlumberger) | Liu, Forrest (Reservoir Engineer - Schlumberger) | Okoroafor, Rita (Schlumberger)
Abstract A key uncertainty associated with Deepwater Turbidites is the reservoir continuity or connectivity, which has been observed in Bonga field. The Bonga field is one of the premier deepwater fields in Nigeria, discovered in 1996 and operated by Shell Nigeria Exploration and Production Company (SNEPCo) since 2005. With several wells under production, water flooding is employed for reservoir pressure management, aiding optimized recovery. Reservoir connectivity uncertainty is a typical issue with these deepwater turbidites, with adequate planning required to ensure risks associated with reservoir connectivity are accounted for and addressed. Although several producer and injector well-pairs have been drilled, data collected and analyzed, connectivity uncertainties still remain high in the field. One key source of information for understanding connectivity issues are formation pressure tests taken periodically (before and during the productive life of these reservoirs). In Deepwater Nigeria, these formation pressures are typically taken while drilling (Formation Pressure tests while drilling - FPWD), and augmented with data from down hole pressure gauges installed in many of the wells. This pressure data is acquired and analyzed to understand the reservoir pressure depletion trend, waterflood patterns and efficiency, as well as identify sand compartments within the reservoir. This paper discusses the use of formation pressure while drilling data in a new Bonga injector. The data was used to confirm connectivity with a paired updip oil producer, which was critical in making real-time decisions on completing the well, reducing drilling and completion risk, as wells as reducing the rig cost associated with the entire well operations.
- Well Drilling > Drilling Measurement, Data Acquisition and Automation > Logging while drilling (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
Application of Experimental Design Techniques to Unravel Sub-Surface Complexity in Gravity Assisted Water Injection Project in the Niger Delta
Onyeukwu, C. A (Shell Petroleum Development Company, Nigeria) | Peacock, A.. (Shell Petroleum Development Company, Nigeria) | Osharode, C. O. (Shell Petroleum Development Company, Nigeria) | Onwuchekwa, C.. (Shell Petroleum Development Company, Nigeria) | Adekoya, O.. (Shell Petroleum Development Company, Nigeria)
Abstract A pilot Gravity Assisted Water (Dumpflood) Injection scheme was executed in 1997 in X1 reservoir of a Niger Delta field โAlphaโ. Post performance analysis showed that the injection has been successful in maintaining good pressure support and in supporting future recovery from the reservoir. However due to X1 reservoir uncertainities and variabilities in Water Dumpfllod injection rates, expected range of future recoveries could not be quantified. This paper presents a case study of the application of Experimental Design (ED) to understand the historical performance and future predictions of a gravity-assisted water injection in โAlphaโ X1 reservoir. A range of static and dynamic models were constructed and experimental design methodology was used to map out the key uncertainties and to develop a range of history matched models which were used to assess the range of future hydrocarbon resource volumes likely to be produced from the reservoir under the existing development concept. In addition to the traditional sub-surface uncertainties, this project also assessed water injection rates as an additional uncertainty that significantly impacted the future recoverable from the reservoir. Experimental design was used to create a range of history matched dynamic models of a dumpflood development that captures the key uncertainties in the reservoir. Ten history matched models were developed and carried to the prediction phase of the study. A voidage replacement development strategy was applied and all ten models were used to predict the reservoir performance over a range of water injection rates. The outcome of the analysis was used to update recoverable volume estimates and to develop a well and reservoir management strategy for the reservoir.
- North America > United States (1.00)
- Africa > Niger (1.00)
- Africa > Nigeria > Niger Delta (0.60)
- Geology > Structural Geology (0.46)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.46)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Africa > Nigeria > Gulf of Guinea > Niger Delta > Niger Delta Basin > OML 95 > Delta Field (0.99)
- Africa > Nigeria > Gulf of Guinea > Niger Delta > Niger Delta Basin > OML 49 > Delta Field (0.99)
- Reservoir Description and Dynamics > Reservoir Simulation > History matching (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
Abstract The success of any green as well as mature field development planning and execution lies in the ability to recreate the environment of deposition with the appropriate spatial and temporal facies interdependencies. This, when done with proper application of the varied suite of geotechnical software/knowhow, often leads to the creation of a finite number of high resolution and equiprobable reservoir models within a macro and micro sedimentological framework, that readily lends itself to optimized risk and uncertainty management. This becomes even more critical in deepwater turbidite systems where the impact of geologic uncertainties can significantly reduce project value and does often prevent marginal field developments in the absence of a low cost tie-in option. This paper presents the novel application of one such technique; the QuantiMin methodology approach improves aspects of reservoir characterization and facilitates various aspects of well and reservoir management in the waterflood development of a Miocene deepwater turbidite system in the Gulf of Guinea. The QuantiMin technique is a sequential quadratic program that solves non-linear problems by series of quadratic programming steps. When applied in this context, it assesses the mineral and fluid content around the near wellbore area, based on their unique well log responses, and returns with a finite volume distribution of mineral and fluid distribution around the wellbore, using the mineral and fluid distribution input from appraisal well cores as the calibration or control variable. The results from QuantiMin analysis have been used in this field to: Evaluate the potential impact of mineralogy on the performance of water injection wells. Apply understanding of mineral types around the wellbore to the design of acid stimulation recipes. Develop a framework for understanding the field scale distribution of heterogeneities by establishing the interdependencies between log-scale QuantiMin and microscopic core petrography data, and hence facilitate high resolution reservoir characterization. Establish realistic flow potentials for development wells.
- Geology > Sedimentary Geology > Depositional Environment > Marine Environment > Deep Water Marine Environment (1.00)
- Geology > Mineral (1.00)
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 186 > Field A Field > Silurian Tanezzuft Formation (0.97)
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 115 > Field A Field > Silurian Tanezzuft Formation (0.97)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Management > Asset and Portfolio Management > Field development optimization and planning (1.00)
Abstract This paper presents the results of the study that was initiated to investigate the incremental benefit of gas and/or water injection in the production of oil rim reservoirs. Due to the nature of the project, emphasis had been on maximizing oil recovery. Consequently, only the incremental oil recovery was used to screen development concepts with a view to optimizing the overall economic value of the concept. This paper includes reservoir simulation on oil rim development with gas and/or water injection with sensitivities on: 1) Permeability anisotropy, Kv/kh 2)GOR relaxation policy 3) Aquifer strength 4) Oil Column Thickness (Ho) 5) Well placement. Results of this study suggest that simultaneous gas and water injection (voidage replacement maintained) could increase recovery factors by upto 15% of STOIIP.
- Africa > Nigeria (0.69)
- Asia > Middle East (0.46)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Asia > Malaysia > Sabah > South China Sea > Sabah Basin > Block SB301 > Samarang Field (0.99)
- Africa > Nigeria > Gulf of Guinea > Niger Delta > Niger Delta Basin > OML 133 > Erha Field (0.99)
- Africa > Middle East > Egypt > Western Desert > Kareem Field (0.99)
- North America > United States > Arkansas > Smart Field (0.93)
Effective and Innovative Approach to Integrating Static and Dynamic data: A key to Volumes Optimization in Erha Field
Mudi, K. C. (Esso Exploration and Production Nigeria Limited) | Idih, R. E. (Esso Exploration and Production Nigeria Limited) | Sarumi, O. S. (Esso Exploration and Production Nigeria Limited) | Etta, C. O. (Esso Exploration and Production Nigeria Limited) | Ejayeriese, A. O. (Esso Exploration and Production Nigeria Limited) | Nwogbo, N. C. (Esso Exploration and Production Nigeria Limited) | Oke, A. A. (Esso Exploration and Production Nigeria Limited)
Abstract Erha field is a stacked deepwater slope confined channel complex system. Vertical and lateral communication between channel sets and individual channel sands is hampered by a series of cross cutting faults and a complex vertical channel stacking pattern. The principal depletion mechanism in Erha is gas-cap drive with support from both gas and water injection to effect simultaneous closure of the GOC and the OWC around producer completions. Erha field currently produces about 85 kBOPD & 340 Mscfd gas with a STOOIP of 1.46 GBO and a 34% recovery factor. Year End 2010 recovery is 220 MBO. A key challenge for interpretation and surveillance is the identification of flow barriers/baffles. The complex geology and degree of compartmentalization make it difficult to define reservoir connectivity between the channel complex sets. Gas channeling through high permeability pathways is a major challenge in Erha with 6 wells shut in due to high GOR and the remaining 9 producers showing elevated GORs. A key opportunity therefore is the development of a reservoir management plan that accounts for these complexities and performance. The Erha subsurface team, including representatives from geology and reservoir engineering, has identified potential baffles and barriers by integrating static and dynamic reservoir data. As a result, a revised gas injection strategy was initiated, significantly mitigating gas channeling and thereby improving oil rates, prolonging well lives and maximizing the asset value. Additionally, the improved description of reservoir connectivity underpinned the development of new geologic and simulation models that will be used in the determination of potential bypassed oil and infill drill wells/completion strategies.
- Africa > Nigeria > Gulf of Guinea > Niger Delta (0.92)
- North America > United States > Texas (0.69)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.36)
- Africa > Nigeria > Gulf of Guinea > Niger Delta > Niger Delta Basin > OML 133 > Erha Field (0.99)
- North America > United States > Texas > Permian Basin > Midland Basin > Good Field (0.97)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Reserves Evaluation (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Gas-injection methods (1.00)